Instrumentation system and method

ABSTRACT

An instrumentation system includes a detection apparatus and a data logging apparatus that detect and record various inflow parameters and outflow parameters of the well during the completion phase or other operational phase of the well. The detection apparatus includes instrumentation that is applied to both the inflow into the well and the outflow out of the well and that detects the inflow and outflow parameters. The data logging apparatus captures the output from such instrumentation and records it for analysis. Such analysis can be performed in real time, i.e., as the data is being recorded, and/or can be retrieved at a later time for analysis and for optimization of future wells. A method involves applying the instrumentation system to a well.

CROSS-REFERENCE TO RELATED APPLICATION

The instant application claims priority from U.S. Provisional PatentApplication Ser. No. 62/289,228, filed Jan. 30, 2016; U.S. ProvisionalPatent Application Ser. No. 62/327,707 filed Apr. 26, 2016; U.S.Provisional Patent Application Ser. No. 62/420,194 filed Nov. 10, 2016;U.S. Provisional Patent Application Ser. No. 62/420,206 filed Nov. 10,2016; and U.S. Provisional Patent Application Ser. No. 62/423,954 filedNov. 18, 2016, the disclosures of which are incorporated herein byreference.

BACKGROUND

Field

The disclosed and claimed concept relates generally to aninstrumentation system and, more particularly, to an instrumentationsystem that is usable in conjunction with a well such as a fossil fuelwell.

Related Art

Numerous types of subterranean wells are known to exist in the relevantart. Such wells typically are employed in order to remove subterraneanresources that are in a fluid or fluidized state. Such wells caninclude, for example, water wells and also can include wells that removehydrocarbons from subterranean locations, such as petroleum wells. Otherwells remove materials that would be in a gaseous state at atmosphericpressure. Some such gas wells involve a reservoir that includes a pocketof, for instance, natural gas and/or other substances that can includeother hydrocarbons, and the pocket is tapped in order to cause thematerials in the pocket to be brought to the surface for use. Anothersuch gas well implementation is one in which the hydrocarbons are lockedwithin a shale matrix and must be subjected to a hydraulic fracturingoperation in order to free the hydrocarbons for removal to the surface.

Such a hydraulic fracturing operation typically involves the drilling ofa hole into the surface of the earth and the installation of a pair ofconcentric pipes in the hole that can be said to include an outer pipeand an inner pipe, wherein an annular region is formed between the innerand outer pipes. The hydraulic fracturing operation further includes theinstallation of a number of plugs at various vertical locations withinthe inner pipe. As employed herein, the expression “a number of” andvariations thereof shall refer broadly to any non-zero quantity,including a quantity of one. As each successive plug is installed, theregion of the earth vertically below the plug is subjected to ahydraulic fracturing operation that involves a pressurized fluid and aproppant such as sand or other material in a known fashion. After all ofthe hydraulic fracturing operations are performed in the hole, the plugstypically are removed in what is generally known as a completion phase.

In the completion phase, a drill bit having a turbomachinery motor isreceived in the inner pipe. A fluid at a high pressure and a highvelocity, such as water with polymers and other additives, is pumpedinto the inner pipe in order to operate the turbomachine in order topower the drill bit, and the drill bit thus drills through the variousplugs. The fluid is generally removed from the well by causing it toflow through the annular region between the inner and outer pipes backto the surface whereby it can carry parts of the plugs and mayadditionally carry other materials such as dirt and hydrocarbons. Thereturned fluid typically is caused to be received in a number ofreclamation tanks, after which it is reconditioned as needed and pumpedback into the inner pipe in order to continue to power the drill bit.The system employed a pressure pumper to pump the fluid into the welland to power the turbomachine motor that operates the drill bit.However, the system typically also includes a choke on theoutward-flowing fluid path that is adjusted in order to maintain acertain downhole pressure and that serves as counterbalancing pressureto the pressure provided by the pressure pumper to the inward flow offluid.

While such completion operations have been generally effective for theirintended purposes, they have not been without limitation. A strap stickor other such manual tool was typically received in the reclamationtank, and the change in height of the fluid in the reclamation tanktypically was visually observed. If the fluid level in the reclamationtank was observed to be increasing, a command typically was issued toreduce the velocity of the pressure pumper that was pumping the fluidinto the well or to narrow the setting on the choke, or both. On theother hand, if the level of the fluid in the reclamation tank was seento be dropping, the pressure pumper typically may have been instructedto increase its speed, or the setting on the choke was widened. This wastypically done in order to achieve a volumetrically balanced type offlow into and out of the well. Depending upon the state of the pressurepumper and the state of the choke, the well could be in an overbalancedstate wherein material was flowing from the pipes and into thereservoir, which is undesirable. Likewise, the well could alternativelybe in an underbalanced state wherein material is flowing from thereservoir into the pipe and flowing out of the well and into thereclamation tanks, by way of example. The overbalanced and underbalancedstates are both undesirable. Other such undesirable conditions can existin the well during the completion phase. While such manual measurementtools such as the strap stick were employed, along with other suchmanual measuring tools such as the use of stopwatches and the manualcounting of pump cycles, such manual measurement devices provided atmost only an incomplete view of the operational state of the well.Improvements thus would be desirable.

SUMMARY

These and other shortcoming are addressed by an improved instrumentationsystem and method in accordance with the disclosed and claimed concept.The instrumentation system includes a detection apparatus and a datalogging apparatus that detect and record various inflow parameters andoutflow parameters of the well during the completion phase or otheroperational phase of the well. The detection apparatus includesinstrumentation that is applied to both the inflow into the well and theoutflow out of the well and that detects the inflow and outflowparameters. The data logging apparatus captures the output from suchinstrumentation and records it for analysis. Such analysis can beperformed in real time, i.e., as the data is being recorded, and/or canbe retrieved at a later time for analysis and for optimization of futurewells.

Accordingly, an aspect of the disclosed and claimed concept is toprovide an instrumentation system for a well that providesinstrumentation on both an inward flow into the well and an outward flowout of the well, and that can record and retain such data.

Another aspect of the disclosed and claimed concept is to provide suchan instrumentation system wherein the stored data can be retrieved forreal time analysis or can be retrieved later for other purposes such asoptimization of future wells, and for other purposes.

Accordingly, an aspect of the disclosed and claimed concept is toprovide an improved instrumentation system structured to be used inconjunction with a well that is formed in a surface, the well having afluid inflow channel through which an inward flow of fluid can be causedto travel in a direction generally from the surface into the well, thewell further having a fluid outflow channel through which an outwardflow of fluid can be caused to travel in a direction generally outwardfrom the well to the surface. The instrumentation system can begenerally stated as including a detection apparatus that can begenerally stated as including an inlet instrumentation package and anoutlet instrumentation package, the inlet instrumentation package can begenerally stated as including a plurality of sensing elements, eachsensing element of the plurality of sensing elements being structured todetect an inflow parameter of the inward flow and to generate an inflowdata signal based at least in part upon the inflow parameter, the outletinstrumentation package can be generally stated as including a pluralityof other sensing elements, each other sensing element of the pluralityof other sensing elements being structured to detect an outflowparameter of the outward flow and to generate an outflow data signalbased at least in part upon the outflow parameter, and a data loggingapparatus that can be generally stated as including a communicationsystem and a processor apparatus, the communication system beingstructured to receive the inflow data signals and the outflow datasignals, the processor apparatus can be generally stated as including aprocessor and a storage, the processor being structured to receive theinflow data signals and the outflow data signals from the communicationsystem, the processor being further structured to store at least some ofthe inflow data signals and the outflow data signals in the storage.

Another aspect of the disclosed and claimed concept is to provide animproved method of detecting a plurality of operational parameters of awell that is formed in a surface, the well having a fluid inflow channelthrough which an inward flow of fluid is caused to travel in a directiongenerally from the surface into the well, the well further having afluid outflow channel through which an outward flow of fluid is causedto travel in a direction generally outward from the well to the surface.The method can be generally stated as including applying to the well aninstrumentation system that can be generally stated as including adetection apparatus can be generally stated as including an inletinstrumentation package and an outlet instrumentation package, the inletinstrumentation package can be generally stated as including a pluralityof sensing elements, each sensing element of the plurality of sensingelements detecting an inflow parameter of the inward flow and generatingan inflow data signal based at least in part upon the inflow parameter,the outlet instrumentation package can be generally stated as includinga plurality of other sensing elements, each other sensing element of theplurality of other sensing elements detecting an outflow parameter ofthe outward flow and generating an outflow data signal based at least inpart upon the outflow parameter, and a data logging apparatus that canbe generally stated as including a communication system and a processorapparatus, the communication system receiving the inflow data signalsand the outflow data signals, the processor apparatus can be generallystated as including a processor and a storage, the processor receivingthe inflow data signals and the outflow data signals from thecommunication system, the processor storing at least some of the inflowdata signals and the outflow data signals in the storage.

DRAWINGS

A further understanding of the disclosed and claimed concept can begained from the following Description when read in conjunction with theaccompanying drawings in which:

FIG. 1 is a schematic depiction of an improved instrumentation system inaccordance with the disclosed and claimed concept; and

FIG. 2 is a detailed depiction of a detection apparatus of theinstrumentation system of FIG. 1.

Similar numerals refer to similar parts through the specification.

DESCRIPTION

An improved instrumentation system 4 in accordance with the disclosedand claimed concept is depicted generally in FIGS. 1 and 2. Theinstrumentation system is usable in conjunction with a well 6 which, inthe depicted exemplary embodiment, is a fossil fuel well and, moreparticularly, it is a shale gas well. It is understood that other typesof wells, including those that do not involve fossil fuels, can have theinstrumentation system 4 applied thereto without limitation. Theinstrumentation system 4 is depicted in FIG. 1 as being in communicationwith a Christmas tree 8 that is situated atop the well 6 and whichperforms control functions and other functions of the type that aregenerally known in the relevant art. As can be understood from FIG. 1,the well 6 is formed in a surface 10 of the earth and is usable to causematerials from within the earth to be brought to the surface 10 forextraction, use, etc.

The Christmas tree 8 is part of a flow circuit 12 that is depictedgenerally in FIG. 2 and which is situated generally above and upon thesurface 10. The well 6 itself includes a pair of concentric pipes thatextend below the surface 10 and that form a fluid inflow channel 14within the inner pipe and a fluid outflow channel 16 in the annularregion between the inner pipe and the outer pipe. During certainoperations involving the well 6, an inward flow of fluid 18 flows intothe Christmas tree 8 and thereafter into the fluid inflow channel 14 andflows in a direction generally from the surface 10 downward into thewell 6. Likewise, an outward flow of fluid 20 is caused to flow in thefluid outflow channel 16 in a direction generally upward from the well 6toward and out of the surface 10.

The circulation fluid that is provided as the inward flow of fluid 18and that is returned as the outward flow of fluid 20 typically is fowledprimarily of water and known polymer materials that facilitate flow ofthe fluid into the well 6 and that promote similar flow out of the well6 carrying particles of plugs that have been installed within the well 6and subsequently drilled out using a drill bit. As such, the outwardflow of fluid typically includes the water infused with polymers (alongwith other additives) and further carries with it particles ofdrilled-out plugs and may additionally carry with it hydrocarbons andproppant material of a type that is known in the relevant art.

As can be understood from FIG. 1, the instrumentation system 4 can besaid to include a detection apparatus 22 and a data logging apparatus 24that are in communication with one another. More particularly, and aswill be set forth in greater detail below, the detection apparatus 22detects certain parameters of the inward and outward flows of fluid 18and 20 and communicates data signals representative of such parametersto the data logging apparatus 24. It is understood that any type of dataconnection between the detection apparatus 22 and the data loggingapparatus 24 can be used without limitation. While FIG. 1 depicts awired connection between the detection apparatus 22 and the data loggingapparatus 24, it is understood that any type of wireless or other typeof data communication systems therebetween can be employed withoutlimitation.

The detection apparatus 22 can be said to include an inletinstrumentation package 26 and an outlet instrumentation package 28. Theinlet instrumentation package 26 includes a plurality of instrumentsthat are in communication with the inward flow of fluid 18, meaning thatthey are in physical proximity to the inward flow of fluid 18 or are influid communication with the inward flow of fluid 18 depending upon theneeds of the various instruments. In a similar fashion, the outletinstrumentation package 28 is in communication with the outward flow offluid 20, and such communication may be the state of being in proximitywith or in fluid communication with the outward flow of fluid 20depending upon the needs of the particular instruments that make up theoutlet instrumentation package 28.

More specifically, and as can be seen in FIG. 2, the flow circuit 12includes an inflow leg 30 that brings the circulation fluid to theChristmas tree 8 for flow into the fluid inflow channel 14. The flowcircuit 12 further includes an outflow leg 32 that carries thecirculation fluid away from the Christmas tree 8 after flowing out ofthe fluid outflow channel 16. The inlet instrumentation package 26 issituated on or in proximity to the inflow leg 30, and the outletinstrumentation package 28 likewise is situated on or in proximity tothe outflow leg 32.

As can further be seen in FIG. 2, the outflow leg 32 can be said toinclude a set of of outflow piping 34 that is connected between theChristmas tree 8 and a set reclamation tanks 36 and which receives thecirculation fluid. The reclamation tanks 36 penult the settling ofcertain particulate materials and the venting of certain volatilematerials and serve other purposes that are known in the relevant art. Atransfer pump 38 pumps the circulation fluid from the reclamation tanks36 through a filtration system 40 and into a water tank farm 42 wherethe circulation fluid is stored. A delivery pump 44 then pumps thecirculation fluid from the water tank farm 42 into a mixing pit 46 whereadditional polymer materials and other materials can be added to thecirculation fluid to replenish anything that may have been lost eitherdownhole or otherwise. It is noted that within the outflow leg 32, achoke 49 is situated upstream of a separator 48. The separator 48 isconnected with a flare 50 that ignites volatile gaseous material thatmay be of hydrocarbon content, for example, and that may have beencarried out of the well 6 as part of the outward flow of fluid 20.

As can further be seen in FIG. 2, the inflow leg 30 can be said toinclude a set of inflow piping 52 and a pressurizing pump 54 that drawsthe circulation fluid from within the mixing pit 46. The pressuring pump54 then pumps the circulation fluid toward a service rig 56 andthereafter into the Christmas tree 8 and into the fluid inflow channel14. It is understood that the exemplary depiction of the flow circuit 12is not intended to be limiting in any fashion.

The inlet instrumentation package 26 can be said to include a pluralityof inflow instruments 58 that are described in greater detail below. Theinflow instruments 58 can be mounted directly to the inflow leg 30 asindividual instruments in a fashion that is suited to the operationalneeds of the various inflow instruments 58. Alternatively, the inflowinstruments 58 can be mounted to a housing having a fluid inlet and afluid outlet that can be placed in fluid communication with the inflowleg 30 without departing from the spirit of the instant disclosure.

The inflow instruments 58 in the depicted exemplary embodiment include atemperature sensor 60, a pressure sensor 62, a volumetric flow meter 64,and a viscometer 66. The exemplary temperature sensor 60 in the depictedexemplary embodiment is placed directly in contact with the fluid flowwithin the inflow leg 30 and can be (please provide an exemplary modelnumber, manufacturer, and manufacturer location), although othertemperature sensors can be employed without departing from the spirit ofthe present concept. The pressure sensor 62 is likewise placed in fluidcommunication with the inflow leg 30 and can be (please provide anexemplary model number, manufacturer, and manufacturer location) orother appropriate pressure sensor.

The volumetric flow meter 64 can be any of a wide variety of flow metersand particularly may include an ultrasonic flow meter, of which numeroustypes are known to exist. An ultrasonic flow meter need not necessarilybe directly in fluid communication with the inflow leg 30 and ratherneed only be within a predetermined proximity of the inflow leg 30 inorder to detect the flow rate of the fluid within the inflow leg 30.Since the volumetric flow meter 64 is on what can be termed the “clean”side of the flow circuit 12, i.e., on the inflow leg 30, an appropriateultrasonic volumetric flow meter would be a transit time meter such as(please provide an exemplary model number, manufacturer, andmanufacturer location), although other types of flow meters can beemployed without limitation.

The viscometer 66 is depicted as being situated between the mixing pit46 and the pressurizing pump 54 and is situated within such flow, i.e.,in fluid communication therewith. The viscometer 66 can, for example, be(please provide an exemplary model number, manufacturer, andmanufacturer location), although other viscometers can be employedwithout departing from the spirit of the present disclosure.

The outlet instrumentation package 28 can likewise be said to include aplurality of outflow instruments 66 that are placed in communicationwith the outward flow of fluid 20, meaning that they are placed eitherin proximity to the outflow leg 32 or in fluid communication with theoutward flow of fluid 20 within the outward flow leg 32. It is notedthat the inflow instruments 58 and the outflow instruments 68 arepreferably placed at least ten pipe diameters from an upstream flowchange such as an elbow or the like, and are further preferably placedat least five pipe diameters from a downstream flow change such as anelbow, etc.

The outflow instruments 68 include a temperature sensor 70 and apressure sensor 72 that may be similar to the temperature sensor 60 andthe pressure sensor 62, although other instrumentation can be employeddepending upon the needs of the particular application. The outflowinstruments 68 further include a volumetric flow meter 74 which may ormay not be similar to the volumetric flow meter 64. Inasmuch as thevolumetric flow meter 74 can be said to be on what can be termed the“dirty” side of the flow circuit 12, the volumetric flow meter 74 mayadvantageously employ a Doppler sensing system that relies uponparticulate material that is carried within the outward flow of fluid 20in order to measure the volumetric flow rate. Further advantageously,the volumetric flow meter 74 may be of a hybrid variety that employs notonly the Doppler technology but may additionally employ transit timeultrasonic technology and can switch between the two depending upon theamount of particulate material within the outward flow of material 20 atany given time. The volumetric flow meter 74 may be (please provide anexemplary model number, manufacturer, and manufacturer location),although other appropriate volumetric flow meters can be employedwithout departing from the spirit of the present disclosure.

The outflow instruments 68 further include a viscometer 66 that issituated in the flow of circulation fluid and is disposed immediatelyprior to the mixing pit 46. The viscometer 66 thus measures theviscosity of the circulation fluid immediately before it reaches themixing pit 46. Inasmuch as the viscometer 76 measures the viscosity ofthe circulation fluid immediately after it leaves the mixing pit 46, theviscosity values that are output by the viscometers 66 and 76 enableappropriate materials, such as polymer materials and other knownmaterials, to be added to the mixing pit 46 in order to achieve adesirable mixture, as measured by its viscosity, on the circulationfluid leaving the mixing pit 46.

The outflow instruments 68 further include a mass flow meter 78 that maybe a Coriolis mass flow meter or an electromagnetic mass flow meter, byway of example and without limitation. If the mass flow meter 78 is aCoriolis flow meter, it desirably will be positioned in a verticalorientation such that particulate matter that may be carried in theoutward flow of fluid 20 does not become trapped within the Coriolisflow meter during operation or after periodic shutdowns of the flowcircuit 12. The mass flow meter 78 may be (please provide an exemplarymodel number, manufacturer, and manufacturer location), although otherappropriate mass flow meters can be employed without departing from thespirit of the present concept.

The inflow instruments 58 and the outflow instruments 68 are configuredto detect parameters of the inward flow of fluid 18 and the outward flowof fluid 20, respectively, and such data is communicated as a series ofdata signals from the detection apparatus 22 to the data loggingapparatus 24. For example, the temperature sensor 60 detects as aninflow parameter of the inward flow of fluid 18 a temperature of theinward flow of fluid 18. The temperature sensor 60 then generates aninflow data signal that is representative of or is based at least inpart upon the detected temperature. The inflow data signal is thencommunicated to the data logging apparatus 24. In a like fashion, thepressure sensor 62 detects as an inflow parameter the pressure of theinward flow of fluid 18 and generates an inflow data signal that isrepresentative of or is based at least in part upon the detectedpressure. Likewise, the volumetric flow meter 64 detects as an inflowparameter the volumetric flow rates of the inward flow of fluid 18 andgenerates an inflow data signal that is representative of or is based atleast in part upon the detected volumetric flow rate of the inward flowof fluid 18. Similarly, the viscometer 66 detects as the inflowparameter a viscosity of the inward flow of fluid 18 at the locationbetween the mixing pit 46 and the pressurizing pump 54. The viscometer66 then generates as an inflow data signal a signal that isrepresentative of or is based at least in part upon the detectedviscosity of the inward flow of fluid 18 at such location. All suchinflow data signals are communicated to the data logging apparatus 24.

In a like fashion, the outflow instruments 68 each detect an outflowparameter in the outward flow of fluid 20 and generate an outflow datasignal that is representative of the detected outflow parameter or thatis at least based in part upon the detected outflow parameter. Forinstance, the temperature sensor 70 detects as an outflow parameter thetemperature of the outward flow of fluid 20 and generates an outflowdata signal that is representative of or is based at least in part uponthe detected temperature. The pressure sensor 72 likewise detects as anoutflow parameter a pressure of the outward flow of fluid 20 andgenerates an outflow data signal that is representative of or is basedat least in part upon the detected pressure. The volumetric flow meter74 detects as an outflow parameter the volumetric flow rate of theoutward flow of fluid 20 and generates an outflow data signal that isrepresentative of the volumetric flow rate or is based at least in partupon the detected volumetric flow rate. The viscometer 76 detects as anoutflow parameter a viscosity of the outward flow of fluid 20 at theindicated location and generates an outflow data signal that isrepresentative of the detected viscosity or is based at least in partupon the detected viscosity. Likewise, the mass flow meter 78 detects asan outflow parameter a mass flow rate of the outward flow of fluid 20and generates an outflow data signal that is representative of or isbased at least in part upon the detected mass flow rate. The outflowdata signals are then communicated to the data logging apparatus 24

It is noted that the various inflow data signals and outflow datasignals are, in the depicted exemplary embodiment, communicated in realtime to the data logging apparatus 24. In other embodiments, somestorage of data and burst communication of such data can be employeddepending upon the needs of the particular application.

As suggested above, a wired connection exists between the detectionapparatus 22 and the data logging apparatus 24, which may be in the formof wires that extend between each of the inflow instruments 58 and thedata logging apparatus 24 and that may additionally include wires thatextend between the outflow instruments 68 and the data logging apparatus24. In other embodiments, one or more of the inflow instruments 58 orthe outflow instruments 68 or both can include a wireless datacommunication link that enables the inflow or outflow data signals orboth to be wirelessly communicated directly from the instrument to thedata logging apparatus 24 without departing from the spirit of thepresent concept.

As can be understood from FIG. 1, the data logging apparatus 24 can besaid to include a communications systems 80 that receives the inflowdata signals and the outflow data signals from the detection apparatus22. The data logging apparatus 24 further includes a processor apparatus82 that receives the inflow and outflow data signals from thecommunications system 80 and stores them, potentially with additionalprocessing being involved. The communications system 80 includes awireless transmitter 84 that wirelessly transmits the inflow and outflowdata signals to the processor apparatus 82.

In the depicted exemplary embodiment, the processor apparatus 82includes a processor 86, a storage 88, and a wireless receiver 90. Theprocessor 86 can be any of a wide variety of processors, such asmicroprocessors and the like, without limitation, that perform dataprocessing operations. The storage 88 can be any of a wide variety ofelectronic storage media such as RAM, ROM, EPROM, FLASH, and the likewithout limitation, and serves as a central storage and memory area onthe processor apparatus 82 that interfaces with the processor 86. Thestorage 88 has a number of routines 92 stored therein that areexecutable on the processor 86 to cause the processor 86 and the datalogging apparatus 24 to perform certain desirable operations. Forexample, the operations can include the processing of the inflow andoutflow data signals and the storing in the storage of a set ofoperational data 94 that can be retrieved and viewed in real time orthat can be retrieved at a later date for other purposes.

The wireless receiver 90 is configured to receive the inflow and outflowdata signals from the wireless transmitter 84. In this regard, thedepicted exemplary embodiment shows an external antenna 96 that receivesthe data signals from the wireless transmitter 84 and communicates thedata signals to the wireless receiver 90. The exemplary external antenna96 may be representative of a cellular data communication network or canbe a satellite-based communication network or other type ofcommunication network. Alternatively, the wireless transmitter 84 andthe wireless receiver 90 can communicate directly with one anotherwithout resort to the external antenna 96, and such communication can bewired or wireless. The wireless transmitter 84 and the wireless receiver90 may be in the form of wireless transceivers that can both transmitand receive data, although this need not necessarily be the case.

As noted above, the operational data 94 can be viewed in real timethrough access to the operational data 94 via computers, laptops,smartphones, and the like without limitation. Alternatively, the datacan be saved and reviewed at a later time for purposes such asoptimizing future wells.

When viewed in real time, the various inflow and outflow parameters areuseful to a technician for various purposes. For example, the parameterscan be employed to avoid an overbalanced system and to likewise avoid anunderbalanced system by employing the data to determine how to adjustthe pressurizing pump 54 and the choke 49.

Similarly, the technician may employ the operational data 94 in realtime to determine the existence of a decrease in pressure in the outwardflow of fluid 20 with a corresponding increase in flow rate in theoutward flow of fluid 20 and may determine that a gas pocket or “kick”is imminent. In such a situation, the technician may again take steps toadjust the choke 49 or the pressurizing pump 54 or both in order toavoid the formation of such a gas pocket.

Furthermore, the operational data 94 may be reviewed in real time inorder to maintain a desired flow state, which may be a state that has abalanced volumetric flow in the inward flow of fluid 18 and the outwardflow of fluid 20 or other appropriate flow state. Previously, such wellshad never been instrumented, and the provision of such aninstrumentation system 4 by the inventors enables adjustments of thewell 6 and of the flow circuit 12 in a fashion that increasesefficiency, maximizes flow, and maximizes overall production. Otheradvantages will be apparent.

It is further noted that an advantageous method of detecting a pluralityof parameters of the well 6 is disclosed herein. The advantageous methodincluding applying the instrumentation system 4 to the well 6 andrecording the data that is generated thereby.

While specific embodiments of the disclosed concept have been describedin detail, it will be appreciated by those skilled in the art thatvarious modifications and alternatives to those details could bedeveloped in light of the overall teachings of the disclosure.Accordingly, the particular arrangements disclosed are meant to beillustrative only and not limiting as to the scope of the disclosedconcept which is to be given the full breadth of the claims appended andany and all equivalents thereof.

What is claimed is:
 1. An instrumentation system structured to be usedin conjunction with a well that is formed in a surface, the well havinga fluid inflow channel through which an inward flow of fluid can becaused to travel in a direction generally from the surface into thewell, the well further having a fluid outflow channel through which anoutward flow of fluid can be caused to travel in a direction generallyoutward from the well to the surface, the instrumentation systemcomprising: a detection apparatus comprising an inlet instrumentationpackage and an outlet instrumentation package; the inlet instrumentationpackage comprising a plurality of sensing elements, each sensing elementof the plurality of sensing elements being structured to detect aninflow parameter of the inward flow and to generate an inflow datasignal based at least in part upon the inflow parameter; the outletinstrumentation package comprising a plurality of other sensingelements, each other sensing element of the plurality of other sensingelements being structured to detect an outflow parameter of the outwardflow and to generate an outflow data signal based at least in part uponthe outflow parameter; and a data logging apparatus comprising acommunication system and a processor apparatus, the communication systembeing structured to receive the inflow data signals and the outflow datasignals, the processor apparatus comprising a processor and a storage,the processor being structured to receive the inflow data signals andthe outflow data signals from the communication system, the processorbeing further structured to store at least some of the inflow datasignals and the outflow data signals in the storage.
 2. Theinstrumentation system of claim 1 wherein at least a portion of theinlet instrumentation package is structured to be placed in fluidcommunication with the inward flow, and wherein at least a portion ofthe outlet instrumentation package is structured to be placed in fluidcommunication with the outward flow.
 3. The instrumentation system ofclaim 1 wherein the communication system comprises a wirelesstransmitter that is structured to wirelessly transmit to the processorapparatus an output signal that comprises the inflow data signals fromat least some of the sensing elements of the plurality of sensingelements and the outflow data signals from at least some of the othersensing elements of the plurality of other sensing elements.
 4. Theinstrumentation system of claim 3 wherein the wireless transmittercommunicates the output signal via at least one of a cellular networkand a satellite link.
 5. The instrumentation system of claim 1 whereinthe plurality of sensing elements comprise at least two of a volumetricflow meter, a temperature sensor, and a pressure sensor, and wherein theplurality of other sensing elements comprise at least two of anothervolumetric flow meter, another temperature sensor, and another pressuresensor.
 6. The instrumentation system of claim 5 wherein at least oneof: the plurality of sensing elements further comprising a viscometerthat is structured to detect as the inflow parameter a viscosity of theinward flow; and the plurality of other sensing elements furthercomprising a viscometer that is structured to detect as the outflowparameter a viscosity of the outward flow.
 7. The instrumentation systemof claim 6 wherein at least one of: the plurality of sensing elementsfurther comprising a mass flow meter that is structured to detect as theinflow parameter a mass flow rate of the inward flow; and the pluralityof other sensing elements further comprising a mass flow meter that isstructured to detect as the outflow parameter a mass flow rate of theoutward flow.
 8. The instrumentation system of claim 6 wherein at leastone of: the volumetric flow meter is structured to detect as the inflowparameter a volumetric flow rate of the inward flow; and the anothervolumetric flow meter is structured to detect as the outflow parameter avolumetric flow rate of the outward flow.
 9. The instrumentation systemof claim 8 wherein the storage has stored therein a number of routineswhich, when executed on the processor, cause the processor apparatus toperform a number of operations that comprise: determining a densityvalue of at least one of: based at least in part upon the mass flow rateof the inward flow and the volumetric flow rate of the inward flow, andbased at least in part upon the mass flow rate of the outward flow andthe volumetric flow rate of the outward flow, and storing the densityvalue in the storage.
 10. The instrumentation system of claim 7 whereinthe mass flow meter is a Coriolis flow meter.
 11. A method of detectinga plurality of operational parameters of a well that is formed in asurface, the well having a fluid inflow channel through which an inwardflow of fluid is caused to travel in a direction generally from thesurface into the well, the well further having a fluid outflow channelthrough which an outward flow of fluid is caused to travel in adirection generally outward from the well to the surface, the methodcomprising applying to the well an instrumentation system thatcomprises: a detection apparatus comprising an inlet instrumentationpackage and an outlet instrumentation package; the inlet instrumentationpackage comprising a plurality of sensing elements, each sensing elementof the plurality of sensing elements detecting an inflow parameter ofthe inward flow and generating an inflow data signal based at least inpart upon the inflow parameter; the outlet instrumentation packagecomprising a plurality of other sensing elements, each other sensingelement of the plurality of other sensing elements detecting an outflowparameter of the outward flow and generating an outflow data signalbased at least in part upon the outflow parameter; and a data loggingapparatus comprising a communication system and a processor apparatus,the communication system receiving the inflow data signals and theoutflow data signals, the processor apparatus comprising a processor anda storage, the processor receiving the inflow data signals and theoutflow data signals from the communication system, the processorstoring at least some of the inflow data signals and the outflow datasignals in the storage.